Downhole flow communication-stimulating apparatuses, systems, and methods

ABSTRACT

Disclosed herein is a downhole tool. The downhole tool is conveyable through a wellbore string, extending into a subterranean formation. The wellbore string includes a downhole flow control apparatus, the downhole flow control apparatus including a shearable closure member. The downhole tool is co-operable with the downhole flow control apparatus such that, while the downhole tool is being conveyed downhole within the wellbore string, the downhole tool shears the closure member, with effect that flow communication is established between the wellbore string and the subterranean formation.

CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefits of priority to U.S. Provisional Pat. Application No. 63/332,912, filed Apr. 20, 2022, titled DOWNHOLE FLOW COMMUNICATION-STIMULATING APPARATUSES, SYSTEMS, AND METHODS, the contents of which are hereby expressly incorporated into the present application by reference in their entirety.

FIELD

The present disclosure relates to downhole tools for readying wellbores for production.

BACKGROUND

Simulating and receiving production of fluid from a subterranean formation requires selectively effectuating flow communication between the surface and the subterranean formation. It is desirable to avoid excessive mechanical operations for effectuating such flow communication.

SUMMARY

In one aspect, there is provided a downhole tool, conveyable through a wellbore string, extending into a subterranean formation, the wellbore string including a downhole flow control apparatus, the downhole flow control apparatus including a shearable closure member, wherein the downhole tool is co-operable with the downhole flow control apparatus such that, while the downhole tool is being conveyed downhole within the wellbore string, the downhole tool shears the closure member, with effect that flow communication is established between the wellbore string and the subterranean formation.

In another aspect, there is provided a downhole flow control apparatus for emplacement downhole as part of a wellbore string extending into a subterranean formation, comprising:

-   a shearable closure member; wherein:     -   the shearable closure member is shearable by a downhole tool         being conveyed downhole within the wellbore string, with effect         that flow communication is established between the wellbore         string and the subterranean formation.

In another aspect, there is provided a downhole flow control apparatus for emplacement downhole as part of a wellbore string extending into a subterranean formation, comprising:

-   a housing, defining a housing passage; -   a shearable closure configuration; wherein:     -   the shearable closure configuration and the housing passage         being co-operatively configured such that, in response to         shearing of the shearable closure configuration, flow         communication is established between the housing passage and the         environment external to the via a flow communication         configuration, defined by at least one flow communicator;     -   for each one of the at least one flow communicator,         independently, the establishment of the flow communicator is         responsive to shearing of a respective closure member         configuration of the shearable closure configuration, such that         the shearable closure configuration is defined by at least one         closure member configuration; and     -   for each one of the at least one closure member configuration,         independently, the closure member configuration is defined by a         respective at least one closure member, such that, for each one         of the at least one flow communicator, the shearing of a         respective closure member configuration of the shearable closure         configuration, to which the establishment of the flow         communicator is responsive, is defined by the shearing of the         respective at least one closure member of the respective closure         member configuration.

BRIEF DESCRIPTION OF DRAWINGS

The preferred embodiments will now be described with the following accompanying drawings, in which:

FIG. 1 is a schematic illustration of a system for effecting flow communication between the surface and a subterranean formation via a wellbore;

FIG. 2 is a sectional side view of a portion of an embodiment of a flow control apparatus, illustrating the region of a closure member configuration of the shearable closure configuration.

FIG. 2A is an enlarged view of Detail “A” illustrated in FIG. 2 ;

FIG. 3 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with a downhole tool disposed within a housing passage of the flow control apparatus, prior to registration with a flow communication-stimulating profile;

FIG. 4 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with the downhole tool disposed within a housing passage of the flow control apparatus, with its cutter having become extended in response to registration with the flow communication-stimulating profile, and prior to shearing of the closure member configuration;

FIG. 5 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with the downhole tool disposed within a housing passage of the flow control apparatus, having moved downhole from its position in FIG. 4 , with its cutter still in an extended position after having sheared the closure member configuration;

FIG. 6 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with the downhole tool disposed within a housing passage of the flow control apparatus, having moved downhole from its position in FIG. 5 , and with its cutter having become retracted after having sheared the closure member configuration;

FIG. 7 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with the downhole tool disposed within a housing passage of the flow control apparatus, and having bypassed a closure member configuration without having sheared the closure member configuration with the cutter;

FIG. 8 is a sectional side view of an embodiment of a flow control apparatus having a single flow communicator closed by a single closure member configuration, with the downhole tool disposed within a housing passage of the flow control apparatus, and retained within a non-release profile after having sheared the closure member configuration;

FIG. 9 is a sectional side view of an embodiment of a portion of a flow control apparatus, illustrating the region with the non-release profile, with the downhole tool disposed within a housing passage of the flow control apparatus, and retained within a non-release profile after having sheared the closure member configuration

FIG. 10 is a sectional side view of the portion of the flow control apparatus in FIG. 2 , with the flow communicator disposed in the open condition after the shearing of the closure member configuration;

FIG. 11 is sectional side view another embodiment of a flow control apparatus, having two axially spaced apart flow communicators, with a downhole tool retained within a non-release profile after having sheared the closure member configurations;

FIG. 12 is a sectional side view of the flow control apparatus illustrated in FIG. 11 , prior to the shearing of the closure member configurations;

FIG. 13 is sectional side view of the flow control apparatus in FIG. 11 , with the flow communicators having been established after shearing of the closure member configurations;

FIG. 14 is identical to FIG. 12 , and illustrates spacing between features of the flow control apparatus;

FIG. 15 is identical to FIG. 13 , and illustrates spacing between features of the flow control apparatus; and

FIG. 16 is a top perspective view of an embodiment of a downhole tool that is co-operable with the flow control apparatus.

DETAILED DESCRIPTION

The present disclosure provides apparatuses and systems that can be used in well completion for enabling selective flow communication between a wellbore 102 and a subterranean formation 100.

Referring to FIG. 1 , there is provided a wellbore material transfer system 2 for conducting (e.g. flowing) material from the surface 10 to a subterranean formation 100 via a wellbore 102. In some embodiments, for example, the subterranean formation 100 is a hydrocarbon material-containing reservoir.

The wellbore 102 can be straight, curved, or branched. The wellbore 102 can have various wellbore sections. A wellbore section is an axial length of a wellbore 102. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to “corkscrew” or otherwise vary. The term “horizontal”, when used to describe a wellbore section, refers to a horizontal or highly deviated wellbore section as understood in the art, such as, for example, a wellbore section having a longitudinal axis that is between 70 and 110 degrees from vertical.

In some embodiments, for example, the conducting includes conducting of fluid flow for enabling the downhole deployment of tools. In some embodiments, for example, the conducting includes conducting of treatment material from the surface 10 to the subterranean formation 100 for stimulating the subterranean formation 100 for production of the reservoir fluid.

In some embodiments, for example, the conducting (such as, for example, by flowing) treatment material to the subterranean formation 100 via the wellbore 102 is for effecting selective stimulation of the subterranean formation 100, such as a subterranean formation 100 including a hydrocarbon material-containing reservoir. The stimulation is effected by supplying the treatment material to the subterranean formation 100. In some embodiments, for example, the treatment material includes a liquid, such as a liquid including water. In some embodiments, for example, the liquid includes water and chemical additives. In other embodiments, for example, the stimulation material is a slurry including water and solid particulate matter, such as proppant. In some embodiments, for example the treatment material includes chemical additives. Exemplary chemical additives include acids, sodium chloride, polyacrylamide, ethylene glycol, borate salts, sodium and potassium carbonates, glutaraldehyde, guar gum and other water soluble gels, citric acid, and isopropanol. In some embodiments, for example, the treatment material is supplied to effect hydraulic fracturing of the reservoir.

In some embodiments, for example, the conducting of fluid, to and from the wellhead, is effected via a wellbore string 104. The wellbore string 104 may include pipe, casing 105, or liner, and may also include various forms of tubular segments. The wellbore string 104 defines a wellbore string passage 106 for effecting conduction of fluids between the surface 10 and the subterranean formation 100.

In some embodiments, for example, the wellbore 102 includes a cased-hole completion, in which case, the wellbore string 104 includes a casing 105.

A cased-hole completion involves running casing 105 down into the wellbore 102 through the production zone. The casing 105 at least contributes to the stabilization of the subterranean formation 100 after the wellbore 102 has been completed, by at least contributing to the prevention of the collapse of the subterranean formation 100 that is defining the wellbore 102. In some embodiments, for example, the casing 105 includes one or more successively deployed concentric casing 105 strings, each one of which is positioned within the wellbore 102, having one end extending from the well head. In this respect, the casing 105 strings are typically run back up to the surface. In some embodiments, for example, each casing 105 string includes a plurality of jointed segments of pipe. The jointed segments of pipe typically have threaded connections.

In some embodiments, for example, the annular region between the casing 105 and the subterranean formation 100 is filled with cement for effecting zonal isolation. The cement is disposed between the casing 105 and the subterranean formation 100 for the purpose of effecting isolation of one or more zones of the subterranean formation from fluids disposed in another zone of the subterranean formation. Such fluids include formation fluid being produced from another zone of the subterranean formation 100 (in some embodiments, for example, such formation fluid being flowed through a production string disposed within and extending through the casing 105 to the surface), or injected stimulation material. In some embodiments, for example, the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents produced formation fluids of one zone from being diluted by water from other zones. (c) mitigates corrosion of the casing 105, and (d) at least contributes to the support of the casing 105. The zonal isolation material is introduced to an annular region between the casing 105 and the subterranean formation 100 after the subject casing 105 has been run into the wellbore 102. In some embodiments, for example, the zonal isolation material includes cement.

To effect flow communication between the wellbore 102 and the subterranean formation 100, the wellbore string 104 includes one or more flow communication stations (three flow communication stations 110, 112, 114 are illustrated) are emplaced at the interface between the subterranean formation 100 and the wellbore 102. Successive flow communication stations 110, 112, 114 may be axially spaced from each other along the wellbore 102. In some embodiments, for example, the spacing is such that each one of the flow communication stations 110, 112, 114, independently, is positioned adjacent a respective zone or interval of the subterranean formation 100 for effecting flow communication between the wellbore 102 and the respective zone (or interval).

In some embodiments, for example, the conducting of fluid flow between the surface 10 and the subterranean formation 100, is effected through the passage 106 of the wellbore string 104 via the one or more flow communication stations 110, 112, 114.

In some of these embodiments, for example, the fluid being conducted is conducted downhole, from the surface 10 and to the subterranean formation 100. In those embodiments where the fluid is being conducted downhole, in some of these embodiments, for example, the conducted fluid includes fluid that is urging deployment of downhole tools. In some of these embodiments, for example, the conducted fluid includes treatment material, such that the fluid being conducted is for stimulating production of hydrocarbons from the subterranean formation 100.

In some embodiments, for example, the fluid being conducted is conducted uphole, from the subterranean formation 100 to the surface 10. In this respect, in some of these embodiments, for example, the conducted fluid includes produced hydrocarbons.

In those embodiments where fluid is being conducted downhole from the surface 10 to the subterranean formation 100, in some of these embodiments, for example, to effect flow communication between the surface 10 and the subterranean formation for enabling the conducting of the fluid from the surface 10 to the subterranean formation 100, one or more of the flow communication stations 110, 112, 114 are provided for at least injecting the fluid into the subterranean formation. Each one of the flow communication stations 110, 112, 114, independently, corresponds to a respective zone 100A, 100B, 100C of the subterranean formation 100.

Each one of the one or more flow communication stations 110, 112, 114 includes one or more flow communication apparatuses 200. The flow communication apparatus 200 is configured for integration within the wellbore string 104. The integration may be effected, for example, by way of threading or welding. In some embodiments, for example, the integration is by threaded coupling, and, in this respect, in some embodiments, for example, each one of the uphole and downhole ends, independently, is configured for such threaded coupling to other portions of the wellbore string 104. In some embodiments, for example, the flow communication apparatus 200 is a wellbore sub.

Referring to FIGS. 2 to 13 , in some embodiments, for example, the flow communication apparatus 200 includes a housing 202. The housing 202 includes a housing passage 230. In some embodiments, for example, the housing passage 230 is defined by an inner surface 202A of the housing 202. In some embodiments, for example, the housing 202 includes an uphole port 201A at an uphole end of the apparatus 200, and a downhole port 201B at a downhole end of the apparatus 200, and the housing passage 230 extends between the uphole and downhole flow ports 201A, 201B. The flow communication apparatus 200 is configured for integration within the wellbore string 104 such that the wellbore string passage 106 includes the passage 230. The integration may be effected, for example, by way of threading or welding. In some embodiments, for example, the integration is by threaded coupling, and, in this respect, in some embodiments, for example, each one of the uphole and downhole ends, independently, is configured for such threaded coupling to other portions of the wellbore string 104.

In some embodiments, for example, the housing 202 includes a shearable closure configuration 215. The shearable closure configuration 215 and the housing passage 230 are co-operatively configured such that, in response to shearing of the shearable closure configuration 215, flow communication is established between the housing passage 230 and the environment external to the housing 202.

In some embodiments, for example, the flow communication, established between the housing passage 230 and the environment external to the housing 202, in response to the shearing of the shearable closure configuration 215, is a flow communication via a flow communication configuration 206. In this respect, the flow communication configuration 206 becomes established in response to the shearing of the shearable closure configuration 215. In some embodiments, for example, the flow communication configuration 206 is defined by at least one flow communicator 208.

In those embodiments where the flow communication configuration 206 is defined by at least one flow communicator 208, In some of these embodiments, for example, each one of the at least one flow communicator 208, independently, is disposed within a respective plane. In those embodiments where the flow communication configuration 206 is defined by a plurality of flow communicators, in some of these embodiments, for example, the flow communicators 208 are axially spaced apart, relative to one another, such that the flow communicators define a cluster of flow communicators. In some of these embodiments, for example, the flow communicators 208 are axially spaced apart, relative to one another by a minimum spacing distance “D1” of at least five (5) feet, such as, for example, 7.5 feet, such as, for example, at least ten (10) feet.

In some embodiments, for example, for each one of the at least one flow communicator 208, independently, the flow communicator 208 includes a respective at least one flow passage 208A that extends through the housing 202. For each one of the at least one flow communicator 208, independently, each one of the respective at least one flow passage 208A, independently, extends from a respective internal surface-defined port 210, defined within the internal surface 202A of the housing 202, to a respective external surface-defined port 212, defined within an external surface 202B of the housing 202, such that, for each one of the at least one flow communicator, independently, (i) flow communication with the housing passage 230, with which the flow communicator 208 is disposed, is effected via a respective at least one internal surface-defined port 210, and (ii) flow communication with the environment external to the housing 202, with which the flow communicator 208 is disposed, is effected via a respective at least one external surface-defined port 212.

In those embodiments where the flow communication configuration 206 of the apparatus 200 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 ), such that a plurality of external surface-defined port configurations 208B is defined, in some of these embodiments, for example, each one of the external surface-defined port configurations 208B, independently, is disposed within a respective common plane. In some embodiments, for example, the external surface-defined port configurations 208B are axially spaced apart, relative to one another, such that the external surface-defined port configurations 208B define a cluster of external surface-defined port configurations 208B. In some embodiments, for example, the external surface-defined port configurations 208B are axially spaced apart, relative to one another by a minimum spacing distance “D2” of at least five (5) feet, such as, for example, 7.5 feet, such as, for example, at least ten (10) feet.

In those embodiments where the flow communication configuration 206 of the apparatus 200 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 ), such that a plurality of internal surface-defined port configurations 208C is defined, in some of these embodiments, for example, each one of the internal surface-defined port configurations 208C, independently, is disposed within a respective common plane. In some embodiments, for example, the internal surface-defined port configurations 208C are axially spaced apart, relative to one another, such that the internal surface-defined port configurations 208C define a cluster of internal surface-defined port configurations 208C. In some embodiments, for example, the internal surface-defined port configurations 208C are axially spaced apart, relative to one another by a minimum spacing distance “D3” of at least five (5) feet, such as, for example, 7.5 feet, such as, for example, at least ten (10) feet.

In some embodiments, for example, for each one of the at least one flow communicator 208, independently, the respective at least one flow passage 208A is a respective plurality of circumferentially-spaced flow passages 208A extending through the housing 202, such that the flow communicator 208 includes the respective plurality of circumferentially-spaced flow passages 208A extending through the housing 202. In some of these embodiments, for example, for each one of the at least one flow communicator 208, independently, the respective plurality of circumferentially-spaced flow passages 208A, extending through the housing 202, is disposed within a respective common plane.

In those embodiments where the flow communication configuration 206 of the apparatus 200 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 ), and each one of the flow communicators 208, independently, includes a plurality of circumferentially-spaced flow passages 208A extending through the housing 202, such that, for each one of the flow communicators 208, independently, a respective external surface-defined port configuration is defined by a plurality of circumferentially spaced-apart external surface-defined ports 212, such that a plurality of external surface-defined port configurations is defined, in some of these embodiments, for example, each one of the external surface-defined port configurations, independently, is disposed within a respective common plane.

In those embodiments where the flow communication configuration 206 of the apparatus 200 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 ), and each one of the flow communicators 208, independently, is defined by a plurality of circumferentially-spaced flow passages 208A extending through the housing 202, such that, for each one of the flow communicators 208, independently, a respective internal surface-defined port configuration is defined by the plurality of circumferentially spaced-apart internal surface-defined ports 210, such that a plurality of internal surface-defined port configurations is defined, in some of these embodiments, for example, each one of the internal surface-defined port configurations, independently, is disposed within a respective common plane.

In those embodiments where the flow communication configuration 206 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 ), in some of these embodiments, for example, the external surface-defined port configurations define a cluster of external surface-defined port configurations and the internal surface-defined port configurations define a cluster of internal surface-defined port configurations, such that a cluster of flow communicators 208 is defined.

In those embodiments where the flow communication apparatus 200 is a wellbore sub, in some of these embodiments, for example, the flow communication apparatus 200 includes a single flow communicator 208. In this respect, in those embodiments, where the wellbore string 104 includes a plurality of flow communication stations 110, 112, 114, each one of the flow communication stations 110, 112, 114, independently, includes a respective wellbore sub, such that a plurality of wellbore subs is established within the wellbore string 104, and each one of the wellbore subs, independently, defines a single flow communicator 208, such that each one of the flow communication stations 110, 112, 114, independently, defines a single flow communicator 208.

In some embodiments, for example, the flow communication configuration 206 is configurable in a closed condition (see FIGS. 2 to 4, 7, and 12 ) and in an open condition (FIGS. 5, 6, 8, 10, 11, and 13 ). In the closed condition, flow communication, via the flow communication configuration 206, between the housing passage 230 and the environment external to the housing, is closed. In the open condition, flow communication, via the flow communication configuration 206, between the housing passage 230 and the environment external to the housing 202, is open.

In some embodiments, for example, the shearable closure configuration 215 and the housing passage 230 are co-operatively configured such that, in response to shearing of the shearable closure configuration 215, flow communication becomes established between the housing passage 230 and the environment external to the housing 202 (such that the flow communication configuration 206 becomes established). In this respect, the flow communication configuration 206 and the shearable closure configuration 215 are co-operatively configured such that, in response to the shearing of the shearable closure configuration 215, the closure is defeated, and the flow communication configuration 206 transitions from the closed condition to the open condition.

In some embodiments, for example, the closure of the flow communication configuration 206 is with effect that the sealed interface is established such that the flow communication, via the flow communication configuration 206, between the environment external to the housing 202 and the housing passage 230, is sealed. In this respect, in some embodiments, for example, the housing 202 defines a flow communication configuration 206, and the shearable closure configuration 215 and the flow communication configuration 206 are co-operably configured such that, in the closed condition, the flow communication configuration 206 is sealed by the shearable closure configuration 215. In some embodiments, for example, the shearable closure configuration 215 and the housing passage 230 are co-operatively configured such that, in response to shearing of the shearable closure configuration 215, the sealing interface is defeated, with effect that flow communication is established between the housing passage 230 and the environment external to the housing 202, such that the flow communication configuration 206 becomes disposed in the open condition. In this respect, the flow communication configuration 206 and the shearable closure configuration 215 are co-operatively configured such that, in response to the shearing of the shearable closure configuration 215, the sealing interface is defeated, and the flow communication configuration 206 transitions from the closed condition to the open condition.

In some embodiments, for example, the flow communication configuration 206 is defined by at least one flow communicator 208, and the closed condition of the flow communication configuration 206 is defined by, for each one of the at least one flow communicator, independently, a closure of the flow communicator 208. In some of these embodiments, for example, for each one of the at least one flow communicator 208, independently, the closure of the flow communicator 208 is effectuated by a respective closure member configuration 214, of the shearable closure configuration 215, such that at least one closure member configuration 214 is defined. In some embodiments, for example, each one of the at least one closure member configuration 214, independently, is defined within a respective common plane. In some embodiments, for example, for each one of the at least one closure member configuration 214, independently, the closure member configuration 214 is defined by a respective at least one closure member 216.

In those embodiments where the flow communication configuration 206 includes at least one flow communicator 208, in some of these embodiments, for example, the defeating of the closure of the flow communication configuration 206 is effectuated by defeating of the closed condition of the at least one flow communicator 208. In some of these embodiments, for example, for each one of the at least one flow communicator 208, the defeating of the closure of the flow communicator 208 is effectuated in response to the shearing of the respective closure member configuration 214 (that is respective to the flow communicator 208), such that the defeating of the closed condition of the at least one flow communicator 208, and, therefore, the defeating of the closed condition of the flow communication configuration 206, is effectuated in response to the shearing of the at least one closure member 216 of the respective closure member configuration 214. For each one of the at least one flow communicator 208, independently, the defeating of the closure of the flow communicator 208 is with effect that flow communication is established, via the flow communicator 208, between the housing passage 230 and the environment external to the housing 202, such that the flow communicator 208 becomes disposed in the open condition. In this respect, for each one of the at least one flow communicator 208 of the flow communication configuration 206, the flow communicator 208 and the respective closure member configuration 214 are co-operatively configured such that, in response to the shearing of the at least one closure member 216 of the respective closure member configuration 214, the flow communicator 208 transitions from the closed condition to the open condition.

In some embodiments, for example, for each one of the at least one flow communicator 208 of the flow communicator configuration 206, the closure of the flow communicator 208 by the respective closure member configuration 214, is with effect that a sealed interface is established such that the flow communication, via the flow communicator 208, between the environment external to the housing 202 and the housing passage 230, is sealed by the closure member configuration 214. In some embodiments, for example, for each one of the at least one flow communicator 208 of the flow communication configuration 206, the respective closure member configuration 214 and the housing passage 230 are co-operatively configured such that, in response to the shearing of the respective closure member configuration 214 (defined by the at least one closure member 216), the sealing interface of the flow communicator 208 is defeated, with effect that the flow communication is established, via the flow communicator 208, between the housing passage 230 and the environment external to the housing 202, such that the flow communicator 208 becomes disposed in the open condition. In this respect, for each one of the at least one flow communicator 208 of the flow communication configuration 206, the flow communicator 208 and the respective closure member configuration 214 are co-operatively configured such that, in response to the shearing of the at least one closure member of the respective closure member configuration 214, the sealing interface is defeated, and the flow communicator 208 transitions from the closed condition to the open condition.

In those embodiments where the at least one flow communicator 28 is a plurality of flow communicators 208 (such that the flow communication configuration 206 of the apparatus 200 is defined by a plurality of flow communicators 208 (see FIGS. 11 to 13 )), and for each one of the flow communicators 208, independently, the closure of the flow communicator 208 is effectuated by a respective closure member configuration 214, such that the shearable closure configuration 215 is defined by a plurality of closure member configurations 214, in some of these embodiments, for example, the closure member configurations 214 are axially spaced apart relative to one another. In some embodiments, for example, the closure member configurations 214 are axially spaced apart, relative to one another, by a minimum spacing distance “D4” of at least five (5) feet, such as, for example, at least ten (10) feet.

Referring to FIGS. 2 and 2A, in those embodiments where the shearable closure configuration 215 is co-operable with the housing passage 230 such that, in response to shearing of the shearable closure configuration 215, flow communication becomes established between the housing passage 230 and the environment external to the housing 202 via a flow communication configuration 206, defined by at least one flow communicator 208, and for each one of the at least one flow communicator 208, independently, the establishment of the flow communicator 208 is responsive to shearing of a respective closure member configuration 214 of the shearable closure configuration 215, such that the shearable closure configuration 215 is defined by at least one closure member configuration 214, in some of these embodiments, for example:

for each one of the at least one closure member configuration 214, independently, the closure member configuration 214 is defined by a respective at least one closure member 216, such that, for each one of the at least one flow communicator 208, the shearing of a respective closure member configuration 214 of the shearable closure configuration 215, to which the establishment of the flow communicator 208 is responsive, is defined by the shearing of the respective at least one closure member 216 of the respective closure member configuration 214.

In some embodiments, for example, for each one of the at least one closure member configuration 214, independently, the housing 202 defines, for each one of the respective at least one closure member 216, independently, a respective plug-receiving passage 218 and a respective hollow plug 220. For each one of the respective at least one closure member 216, of each one of the at least one closure member configuration 214, independently, the respective hollow plug 220 defines an open cavity 222 (that is open to, and disposed in fluid communication with, the environment external to the housing 202) and a closed tip 224. For each one of the respective at least one closure member 216, of each one of the at least one closure member configuration 214, independently, the respective hollow plug 220 is disposed within the respective passage 218, in an interference fit relationship with the respective passage 218, and the closed tip 224 extends into the housing passage 220.

In those embodiments where the shearable closure configuration 215 is co-operable with the housing passage 230 such that, in response to shearing of the shearable closure configuration 215, flow communication becomes established between the housing passage 230 and the environment external to the housing 202 via a flow communication configuration 206, defined by at least one flow communicator 208, and for each one of the at least one flow communicator 208, independently, the establishment of the flow communicator 208 is responsive to shearing of a respective closure member configuration 214 of the shearable closure configuration 215, such that the shearable closure configuration is defined by at least one closure member configuration 214, and, for each one of the at least one closure member configuration 214, independently, the closure member configuration 214 is defined by a respective at least one closure member 216, in some of these embodiments, for example:

for each one of the at least one closure member configuration 214, independently, each one of the respective at least one closure member 216, independently, is defined by a respective closed tip 224 of a respective hollow plug 220, disposed within a respective plug-receiving passage 218 of the housing 202, in an interference fit relationship with the respective plug-receiving passage 218, wherein the respective closed tip 224 extends into the housing passage 230, such that, for each one of the at least one closure member configuration 214, independently, a respective at least one closed tip 224 is defined, and such that, for each one of the at least one flow communicator 208, the shearing of a respective closure member configuration 214 of the shearable closure configuration 215, to which the establishment of the flow communicator 208 is responsive, is defined by the shearing of the at least one closed tip 224 that is respective to the respective closure member configuration 214.

In those embodiments where the shearable closure configuration 215 is defined by at least one closure member configuration 214, and the flow communication, established between the housing passage 230 and the environment external to the housing 202, in response to the shearing of the shearable closure configuration 215, is a flow communication via a flow communication configuration 206, defined by at least one flow communicator 208, in some of these embodiments, for example:

the inner surface 202A of the housing 202 defines a flow communication-stimulating profile configuration 231, the flow communication-stimulating profile configuration 231 is defined by at least one flow communication-stimulating profile 232, each one of the at least one flow communication-stimulating profile 232, independently, being configured for receiving a downhole tool 300, being conveyed downhole through the wellbore string passage 106, in response to a lateral displacement (e.g. expansion) of the downhole tool 300, relative to a longitudinal axis 106X of the wellbore string passage 106 (e.g. such that the downhole tool 300 becomes emplaced in a shearing-ready position), such that the downhole tool 300 becomes disposed for shearing of a respective at least one closure member configuration 214 of the shearable closure configuration 215 in response to axial displacement (e.g. in the downhole direction) of the downhole tool 300, relative to the wellbore 102, and, for each one of the at least one flow communication-stimulating profile 232, independently, the shearing of the respective at least one closure member configuration 214, by the downhole tool 300 received by the flow communication-stimulating profile 232, establishes, for each one of the respective at least one closure member configuration 214, independently, a respective one of the at least one flow communicator 208 of the flow communicator configuration 206.

In some embodiments, for example, for each one of the at least one flow communication-stimulating profile 232, independently, the respective at least one closure member configuration 214 is a respective at least one profile-defined closure member configuration 214A which is respective to the flow communication-stimulating profile 232, and for each one of the at least one flow communication-stimulating profile 232, independently, each one of the respective at least one profile-defined closure member configuration 214A, independently, is defined within the flow communication-stimulating profile 232.

In some embodiments, for example, each one of the at least one flow communication-stimulating profile 232, independently, is defined by a respective recess 234 defined within the inner surface 202A.

In those embodiments where the at least one flow communication-stimulating profile 232 is a plurality of flow communication-stimulating profiles 232, in some of these embodiments, for example, the flow communication-stimulating profiles 232 are axially spaced apart, relative to one another by a minimum spacing distance “D5” of at least four (4) feet, such as, for example, seven (7) feet, such as, for example, at least nine (9) feet.

In those embodiments where the at least one closure member configuration 214, of the shearable closure configuration 215, is a plurality of closure member configurations 214 (see FIGS. 11 to 13 ), in some of these embodiments, for example, at least one of the at least one flow communication-stimulating profile 232 is a multi-flow communicator establishing profile, such that at least one multi-flow communicator establishing profile is defined, and, for each one of the at least one multi-flow communicator establishing profile, independently, the receiving of expansion of a downhole tool 300, such that the downhole tool 300 becomes emplaced for shearing of a respective at least one profile-defined closure member configuration 214A of the at least one closure member configuration 214 of the shearable closure configuration 215 in response to axial displacement (e.g. in the downhole direction) of the downhole tool 300, relative to the wellbore 102, is the receiving of expansion of a downhole tool 300, such that the downhole tool 300 becomes emplaced for shearing of a respective plurality of profile-defined closure member configuration 214A, of the plurality of closure member configurations 214 of the shearable closure configuration 215, in response to axial displacement (e.g. in the downhole direction) of the downhole tool 300, relative to the wellbore 102, such that, for each one of the at least one multi-flow communicator establishing profile, independently, the shearing of the respective plurality of profile-defined closure member configurations 214A, by the downhole tool 300 received by the multi-flow communicator establishing profile, establishes, for each one of the respective plurality of profile-defined closure member configurations 214A, independently, a respective flow communicator 208 of the flow communicator configuration 206, such that a respective plurality of flow communicators 208 is established. In some of these embodiments, for example, for each one of the at least one multi-flow communicator establishing profile, independently, the respective plurality of closure member configurations 214 are axially spaced apart, relative to one another by a minimum spacing distance of at least five (5) feet, such as, for example, 7.5 feet, such as, for example, at least ten (10) feet. In some of these embodiments, for example, for each one of the at least one multi-flow communicator establishing profile, independently, the respective plurality of flow communicators 208 are axially spaced apart, relative to one another by a minimum spacing distance of at least five (5) feet, such as, for example, 7.5 feet, such as, for example, at least ten (10) feet.

In some embodiments, for example, the inner surface 202A of the housing 202 defines a non-release profile 240 for receiving the downhole tool, wherein the receiving of the downhole tool, by the non-release profile 240, is with effect that the downhole tool 300 becomes retatined, relative to the wellbore 102, by the non-release profile 204. In some of these embodiments, for example, the retention of the downhole tool 300 is with effect that axial displacement (e.g. in the downhole direction) of the downhole tool 300, relative to the wellbore 102, is prevented. In some embodiments, for example, the non-release profile 240 is configured for receiving a lateral displacement (e.g. expansion) of a downhole tool 300, relative to a longitudinal axis 102X of the wellbore 102, such that the downhole tool 300 becomes emplaced in a retention-ready position, wherein, in the retention-ready position, the downhole tool 300 is disposed for becoming retained within the non-release profile 240 in response to axial displacement (e.g. in the downhole direction) of the downhole tool 300, relative to the wellbore 102. The non-release profile 240 and the shearable configuration are co-operably configured for retention of the downhole tool by the non-release profile 240 after the shearing of at least one closure member configuration of the shearable configuration (see FIGS. 8, 9, and 11 ) by the downhole tool.

In some embodiments, for example, the non-release profile 240 is defined by a recess 241 that is defined within the inner surface 202A of the housing 202. In some embodiments, for example, the recess that defines a flow communication-stimulating profile 232 (of the at least one flow communication-stimulating profile 232), that is closest to the non-release profile 240, is the same recess that defines the non-release profile 240.

In those embodiments where the system 2 further includes the downhole tool 300, in some of these embodiments, for example, the downhole tool 300 is conveyable downhole, via the wellbore 102, by fluid flow (e.g. the downhole tool 300 is carried by fluid flow, such as, for example, by being pumped downhole with the fluid flow), and configured for co-operating with the apparatus 200 for effectuating the shearing of at least one closure member configuration 214 of the shearable closure configuration 215, such that flow communication is established via, for each one of the at least one sheared closure member configuration 214, independently, the respective flow communicator 208 that is established in response to the shearing of the closure member configuration 214 by the downhole tool 300.

In some embodiments, for example, the downhole tool 300 is co-operable with the apparatus 200 such that, while the downhole tool 300 is being conveyed through the housing passage 230 (e.g. in a downhole direction), the downhole tool 300 effectuates the shearing of at least one closure member configuration 214 of the (shearable closure configuration 215). In those embodiments where the shearing of at least one closure member configuration 214 by the downhole tool 300 is a shearing of a plurality of closure member configurations 214 by the downhole tool 300, the shearing of a plurality of closure member configurations 214, by the downhole tool 300, is effectuated sequentially.

In some embodiments, for example, the shearing of each one of the at least one closure member configuration 214, independently, is effectuated via a respective closure member configuration shearing operation, such that the shearing is effectuated via at least one closure member configuration shearing operation. In those embodiments where the shearing of at least one closure member configuration 214 by the downhole tool 300 is a shearing of a plurality of closure member configurations 214 by the downhole tool 300, the shearing is effectuated via a plurality of closure member configuration shearing operations, and the plurality of closure member configuration shearing operations is effectuated sequentially.

In some embodiments, for example, the downhole tool 300 includes a tool profile 304 and a cutter 306. In some embodiments, for example, the cutter 306 is in the form of a cutting blade. In some embodiments, for example, the cutting blade is slightly angled so as to mitigate compression of the downhole tool during the shearing.

In some embodiments, for example, for each one of the at least one closure member configuration, the downhole tool 300 is further co-operable with the apparatus 200 for effectuating, while the downhole tool 300 is being conveyed through the housing passage 230 (e.g. in a downhole direction), a respective profile-stimulated interaction, such that at least one respective profile-stimulated interaction is effectuated. For each one of the at least one respective profile-stimulated interaction, independently, the respective profile-stimulated interaction includes, in sequence: (i) a registration (e.g. an alignment) of the tool profile 304 with a flow communication-stimulating profile 232 (of the flow communication-stimulating profile configuration 231) to which the closure member configuration 214 is respective, (ii) in response to the registration (e.g. based on alignment), a displacement of the cutter 306 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300 (e.g. such that the cutter 306 becomes emplaced in a shearing-ready position), and (iii) a conveyance of the downhole tool 300 through the housing passage 230 in a downhole direction (e.g. while the cutter 306 is disposed in a shearing-ready position), with effect that the shearing of the closure member configuration 214 is effectuated by the cutter (by contact engagement between the cutter 306 and the closure member configuration 214), such that the shearing of the respective closure member configuration, via a respective closure member configuration shearing operation, is effectuated, and such that flow communication is established between the housing passage 230 and the environment external to the housing 202 via the flow communicator 308 established in response to the shearing of the respective closure member configuration 214.

In those embodiments where each one of the at least one flow communication-stimulating profile 232, independently, is defined by a respective recess 234 defined within the respective profile-defining inner surface portion 234, in some of these embodiments, for example, each one of the at least one respective profile-stimulated interaction, independently, includes, after the shearing of the closure member configuration 214, encouragement of retraction of the cutter 306 from the flow communication-stimulating profile 232, such that each one of the at least one respective profile-stimulated interaction, independently, includes,, in sequence: (i) a registration (e.g. based on an alignment) of the tool profile 304 with a flow communication-stimulating profile 232 (of the flow communication-stimulating profile configuration 231) to which the closure member configuration 214 is respective, (ii) in response to the registration (e.g. based on alignment), a displacement of the cutter 306 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300 (e.g. such that the cutter 306 becomes emplaced in a shearing-ready position), (iii) a conveyance of the downhole tool 300 through the housing passage 230 in a downhole direction (e.g. while the cutter 306 is disposed in a shearing-ready position), with effect that the shearing of the respective closure member configuration 214 is effectuated (e.g. by contact engagement between the cutter 306 and the closure member configuration 214), such that the shearing of the respective closure member configuration, via a respective closure member configuration shearing operation, and (iv) encouragement of retraction of the cutter 306 from the flow communication-stimulating profile 232.

In some embodiments, for example, for each one of the at least one profile-stimulated shearing operation, independently, the registration of the tool profile 304 with the flow communication-stimulating profile 232, of the respective flow communication-stimulating interaction, is based upon matching of the tool profile 304 with the flow communication-stimulating profile 232. In this respect, in some embodiments, for example, the tool profile 304 defines a key and the flow communication-stimulating profile 232 defines a key profile, and the registration is established based on matching of the key, defined by the tool profile 304, and the key profile, defined by the flow communication-stimulating profile 232.

In some embodiments, for example, for each one of the at least one profile-stimulated shearing operation, independently, the displacement of the cutter 306 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300, in response to the registration, is urged by a bias.

In some embodiments, for example, the downhole tool 300 includes an elastically deformable portion 318. In some embodiments, for example, the elastically deformable portion 318 is in the form of a C-ring.

In some embodiments, for example, the tool profile 304 and the elastically deformable portion 318 are co-operatively configured such that the tool profile 304 is displaceable (e.g. translatable) with the elastically deformable portion 318. In some embodiments, for example, the cutter 306 and the elastically deformable portion 318 are co-operatively configured such that the cutter 306 is displaceable (e.g. translatable) with the elastically deformable portion 318. In some embodiments, for example, the tool profile 304, the cutter 306, and the elastically deformable portion 318 are co-operatively configured such that each one of the tool profile 304 and the cutter 306, independently, is displaceable (e.g. translatable) with the elastically deformable portion 318. In some embodiments, for example, each one of the tool profile 304 and the cutter 306, independently, is defined by the elastically deformable portion 318, such that the registration is with a profile defined by the elastically deformable portion 318 and the shearing is effectuated by contact engagement between the elastically deformable portion 318 and the closure member configuration 214.

In this respect, the downhole tool 300 and the wellbore string 104 are co-operatively configured such that, while the downhole tool 300 is being conveyed through the wellbore string passage 106, in response to registration of the tool profile 304 with the flow communication-stimulating profile 232, the elastically deformable portion 318 displaces in a laterally outward direction, relative to the central axis 308 of the downhole tool 300. In response to the registration, stress being applied to the deformable portion 318 (and, in some embodiments, for example, compressing the deformable portion 318), by the wellbore string 104, is at least partially removed, with effect that the elastically deformable portion 318 displaces in a laterally outward direction (and, in some embodiments, for example, becomes expanded), relative to the central axis 308 of the downhole tool 300, and, as a corollary, the cutter 306 displaces in a laterally outward direction, relative to the central axis 308 of the downhole tool 300. In this respect, in some embodiments, for example, when the deformable portion 318 is disposed in a compressed state, the deformable portion 318 is biased for displacement in a laterally outward direction, relative to the central axis 308 of the downhole tool 300, such that, in response to the registration of the tool profile 304 with the flow communication-stimulating profile 232, the bias effectuates the displacement of the elastically deformable portion 318 in the laterally outward direction to the shearing-ready position. In this respect, the bias which urges the displacement of the cutter 306 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300, in response to the registration, is the bias which is urging the same displacement of the elastically deformable portion 318.

In some of these embodiments, for example, the downhole tool 300 is configured for further co-operating with the apparatus 200 for becoming retained within the wellbore 102 for interfering with (e.g. sealing) flow communication within the wellbore 102, and thereby selectively diverting fluid that is conducted in the downhole direction within the wellbore 102. In some of these embodiments, for example, the diverting mitigates (such as, for example, prevents) bypassing of at least one uphole-disposed flow communicator 208, of the flow communication configuration 206, disposed uphole relative to the retained downhole tool 300 and effectuating flow communication between the wellbore 102 and the subterranean formation 100, each one of the at least one uphole-disposed flow communicator 208, independently, having become established in response to shearing of a respective uphole-disposed closure member configuration 214, of the shearable configuration 215, disposed uphole relative to the retained downhole tool 300, such that the at least one uphole-disposed flow communicator 208 is established in response to the shearing, by the downhole tool 300, of the at least one uphole-disposed closure member configuration 214, as described above. In some embodiments, for example, the retention of the downhole tool 300 within the wellbore 102, for interfering with (e.g. sealing) flow communication within the wellbore 102, is a retention within the non-release profile 240, and, in such embodiments, for example, for each one of the at least one uphole-disposed closure member configuration 214 that has been sheared, independently, the non-release profile 240 is disposed downhole relative to a flow communication-stimulating profile 232 to which the uphole-disposed closure member configuration 214 is respective.

In some embodiments, for example, the retention of the downhole tool 300, by the non-release profile 240, is effectuated by opposition, by the non-release profile 240, to displacement of the downhole tool 300, relative to the wellbore 102, in the downhole direction. In some of these embodiments, for example, the opposition is effectuated by abutting engagement of a retainable portion 320, of the downhole tool 300, with an opposing surface 242 defined within the non-release profile 240.

In some of these embodiments, for example, the downhole tool is co-operable with the apparatus 200 such that, while the downhole tool 300 is being conveyed through the housing passage 230 (e.g. in a downhole direction), the retention of the downhole tool 300, by the non-release profile 240, is effectuated, in response to a retention-effectuating interaction, and the retention-effectuation interaction includes, in sequence: (i) a registration (e.g. based on alignment) of the tool profile 304 with the non-release profile 240, (ii) in response to the registration, a displacement of a retainable portion 320 of the downhole tool 300 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300 (e.g. such that the retainable portion 320 becomes emplaced in a retention-ready position), and (iii) a conveyance of the downhole tool 300 through the housing passage 230 in a downhole direction (e.g. while the retainable portion 320 is disposed in a retention-ready position), with effect that the retainable portion 320 becomes disposed in abutting engagement with the opposing surface 242 of the non-release profile 240, such that the downhole tool becomes retained to the non-release profile 240.

In some embodiments, for example, the registration of the tool profile 304 with the non-release profile 240 is based upon matching of the tool profile 304 with the non-release profile 240. In this respect, in some embodiments, for example, the tool profile 304 defines a key and the non-release profile 240 defines a key profile, and the registration is established based on matching of the key, defined by the tool profile 304, and the key profile, defined by the non-release profile 240.

In some embodiments, for example, the displacement of the retainable portion 320, in a laterally outward direction, relative to a central axis 308 of the downhole tool 300, in response to the registration of the tool profile 304 with the non-release profile 240, is urged by a bias.

In this respect, in some embodiments, for example, the downhole tool 300, in addition to the tool profile 304 and the cutter 306, also includes the retainable portion 320, and, in some of these embodiments, for example, the retainable portion 320 and the elastically deformable portion 318 are co-operatively configured such that the retainable portion 320 is displaceable (e.g. translatable) with the elastically deformable portion 318. In some embodiments, for example, the tool profile 304, the cutter 306, the retainable portion 320, and the elastically deformable portion 318 are co-operatively configured such that each one of the tool profile 304, the cutter 306, the retainable portion 320, independently, is displaceable (e.g. translatable) with the elastically deformable portion 318. In some embodiments, for example, the elastically deformable portion 318 defines the retainable portion 320, such that the retention by the non-release profile 240 is effectuated by abutting engagement of the elastically deformable portion 318 with the opposing surface 242 of the non-release profile 240. In some embodiments, for example, each one of the tool profile 304, the cutter 306, and the retainable portion 320 is defined by the elastically deformable portion 318, independently, such that the registration is with a profile defined by the elastically deformable portion 318, the shearing is effectuated by the elastically deformable portion 318, and the retention by the non-release profile 240 is effectuated by abutting engagement of the elastically deformable portion 318 with the opposing surface 242 of the non-release profile 240.

The downhole tool 300 and the wellbore string are co-operatively configured such that, while the downhole tool 300 is being conveyed through the wellbore string passage, in response to registration of the tool profile 304 with the non-release profile 240, the elastically deformable portion 318 displaces in a laterally outward direction, relative to the central axis 308 of the downhole tool 300. In response to the registration, stress being applied to the deformable portion 318 (and, in some embodiments, for example, compressing the deformable portion 318), by the wellbore string 104, is at least partially removed, with effect that the elastically deformable portion 318 displaces in a laterally outward direction (and, in some embodiments, for example, becomes expanded), relative to the central axis 308 of the downhole tool 300, and as a corollary, the retainable portion 320 is also displaced in a laterally outward direction relative to the central axis 308 of the downhole tool 300. In this respect, in some embodiments, for example, the deformable portion 318 is biased towards the retention-ready position, and in response to the registration of the tool profile 304 with the non-release profile 240, the bias effectuates the displacement of the elastically deformable portion 318 in the laterally outward direction to the retention-ready position. In this respect, in some embodiments, for example, when the deformable portion 318 is disposed in a compressed state, the deformable portion 318 is biased for displacement in a laterally outward direction, relative to the central axis 308 of the downhole tool 300, such that, in response to the registration of the tool profile 304 with the flow communication-stimulating profile 232, the bias effectuates the displacement of the elastically deformable portion 318 in the laterally outward direction to the shearing-ready position. In this respect, the bias which urges the displacement of the retainable portion 320 in a laterally outward direction, relative to a central axis 308 of the downhole tool 300, in response to the registration, is the bias which is urging the same displacement of the elastically deformable portion 318

In some embodiments, for example, the retained downhole tool 300 is adaptable to establish a closure (e.g. a sealing interface) within the wellbore 102. In this respect, in some embodiments, for example, the retained downhole tool 300 is co-operable with a closure member 315 to define the closure. In some embodiments, for example, the downhole tool 300 includes a seat 312, and the seat 312 is configured to receive a closure member 315, such that the closure member 315 seats on the seat 312. In some embodiments, for example, the closure member 315 is a ball. In some embodiments, for example, the closure member is a disc. While the closure member 315 is seated on the seat 312, the closure member 315 and the seat 312 co-operate to function as a check valve. In this respect, when seated on the seat 312, the closure member 315 and the seat 312 co-operate to close the wellbore string passage 116 (e.g. establish a sealing interface within the wellbore string passage 116), and thereby isolate zones in the subterranean formation, and, in this way, prevent fluid flow in a downhole direction, and also co-operate such that, in response to communication of a downhole fluid pressure, on the downhole side of the closure member 315, that sufficiently exceeds an uphole fluid pressure being communicated on the uphole side of the closure member 315, the closure member 315 becomes displaced from the seat 312, with effect that flow communication and, as a result, fluid flow is established in the uphole direction. In some embodiments, for example, the pressure differential is induced for obtaining flow back to the surface for removing solid material (e.g. proppant) that has accumulated within the wellbore as a result of a screen out, and then permit pump-down of further closure members (e.g. balls) for isolating one or more uphole zones. In some embodiments, for example, a co-operating ball and seat are provided so as to provide the opportunity to effectuate zonal isolation after production by landing a ball on the ball seat after production.

In some embodiments, for example, the downhole tool 300 further includes a sealing configuration 314 defined by one or more sealing members 316. The sealing configuration 314 is co-operable with the wellbore string 104, such that while the downhole tool 300 is being retained within the non-release profile, sealing engagement of the downhole tool 300 to the wellbore string 104 is effectuated, and thereby effectuating the above-described zonal isolation.

In some embodiments, for example, the downhole tool 300 includes an anchor 322, the seat 312, and a lock nut 324. The anchor 322 defines the elastically deformable portion 318, and is in the form of a C-ring. In this respect, in some embodiments, for example, the material of the anchor 322 is alloy steel with minimum yield strength of 100 ksi and a minimum hardness of 20 RC. The anchor 322, by virtue of its definition of the elastically deformable portion 318, also defines the tool profile 304 and the cutter 306. The seat 312 is configured to receive the closure member 315 (e.g. ball), as described above. The lock nut 324 is threaded to the seat 312, and is disposed within a recess 326, defined within the inner surface of the anchor 322, for coupling the anchor 322 to the seat 312. The coupling is with effect that axial displacement of the anchor 322, relative to the seat 312, is limited (e.g. prevented), while permitting elastic deformation (expansion/contraction) of the anchor 322, for effectuating, independently, the shearing of the at least one closure member configuration by the cutter 306 and the retention of the downhole tool 300 by the retainable portion 320. In the illustrated embodiment, the sealing configuration 314 is defined by two sealing members 316 that are carried by the seat 312.

In some embodiments, for example, the downhole tool 300 is co-operable with the apparatus such that conveyance of the downhole tool 300 through the housing passage 230 (e.g. in a downhole direction) is with effect that the downhole tool 300, in sequence, (i) shears the at least one closure member configuration 214, and (ii) becomes retained within the wellbore 102. In some of these embodiments, for example, the shearing is effectuated by the at least one closure member configuration shearing operation, and the retention of the downhole tool 300 is the retention by the non-release profile 240, and is effectuated in response to the retention-effectuating interaction.

In some embodiments, for example, and as discussed above, the system 2 includes a wellbore string 104 that includes a plurality of flow communication stations (three flow communication stations, 110, 112, 114 are shown). Each one of the flow communication stations 110, 112, 114, independently, corresponds to a respective zone 100A, 100B, 100C of the subterranean formation 100, and includes one or more flow communication apparatuses 200. To stimulate production of hydrocarbon material from the subterranean formation 100, treatment material is injected via the apparatus of the flow communication stations 110A, 110B, 110C, successively, in an uphole direction. In this respect, a downhole tool 300 is conveyed downhole via fluid flow (which, in some embodiments, for example, is discharged through a toe valve) to the flow communication station 110C for establishing flow communication with the zone 100C by shearing the shearable closure configuration 215 associated with an apparatus 200 of the flow communication station 110C. To become emplaced within the flow communications station 110C, the downhole tool 300, passes the apparatuses 200 of the flow communication stations 110 and 112. While passing the apparatuses 200 of the uphole flow communication stations 100, it is desirable that the downhole tool 300 does not shear any of the shearable closure configurations 300 of the uphole apparatuses 200, or become retained within any of the non-release profiles 240 of the uphole apparatuses 200. In order to avoid these outcomes, the tool profile 304 of the downhole tool 300, the flow communication-stimulating profiles 230 of all of the uphole apparatuses, and the non-release profiles 240 of all of the uphole apparatuses 200 are co-operatively configured such that, while the downhole tool 300 passes the uphole apparatuses 200, there is an absence of matching between the tool profile 304 and: (i) all of the flow communication-stimulating profiles 230 of the uphole apparatuses 200, and (ii) all of the non-release profiles 240 of the uphole apparatuses 200. After the downhole tool 300 has passed all of the uphole apparatuses 200, and while continuing to be conveyed downhole through the furthest downhole apparatus 200 of the flow communication station 110C, its tool profile 304 registers with a flow communication-stimulating profile 232, thereby, initiating a flow communication-stimulating interaction, resulting in the shearing of the associated closure member configuration, with effect that flow communication is established between the housing passage 230 and the environment external to the housing 202, releases from the flow communication-stimulating profile 232, and then becomes retained to the non-release profile 240. The ball 315 is pumped down, with effect that the ball 315 becomes seated on the seat 312, thereby effectuating desired zonal isolation. With the flow communication and zonal isolation established, treatment material is injected into the subterranean formation through the flow communication station 110C for stimulating production of hydrocarbon material. Once sufficient treatment material is injected, another downhole tool 300, having a tool profile 304 which matches the flow communication-stimulating profile 232 and the non-release profile 240 of the next uphole apparatus 200, but does not match any of the flow communication-stimulating profiles 230 of all of the uphole apparatuses 200, or any of the non-release profiles 240 of all of the uphole apparatuses 200, is then pumped downhole, so as to create conditions for enabling the injection of treatment material through the next uphole apparatus 200. This process is repeated for all of the apparatuses 200 of the flow communication stations so as to create conditions for enabling injection of treatment material through all of the desired zones of the subterranean formation 100, for stimulating hydrocarbon production in such zones. After the desired treatment material has been injected, hydrocarbon material is producible from the subterranean formation.

In some embodiments, for example, to facilitate production, the downhole tool 300 includes components comprising of degradable material. In some embodiments, for example, each one of the closure member 315 and the seat 312, independently, is comprised of degradable material. In some embodiments, for example, the sealing configuration is comprised of degradable material. In some embodiments, for example, the entirety of the downhole tool 300 is comprised of degradable material.

In some embodiments, for example, the degradable material is configured for milling out.

In some embodiments, for example, the degradable material is co-operable with a degradation promoting agent such that, in response to emplacement of the degradable material in mass transfer communication with the degradation promoting agent, the degradable material becomes degraded, with effect that there is established reduced interference, from the degradable material, to the production. In some embodiments, for example, the degradation-promoting agent is a chemical agent, such as, for example, an acid. In some embodiments, for example, the degradation-promoting agent is wellbore fluids. In some embodiments, for example, the degradable material is a dissolvable metal material. In some embodiments, for example, the degradable material includes at least one of degradable aluminium and degradable magnesium.

Although the embodiments have been described in detail, it should be understood that various changes, substitutions and alterations can be made herein. Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the disclosure of the present invention, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed, that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.

As can be understood, the examples described above and illustrated are intended to be examples only. The invention is defined by the appended claims. 

1. A downhole tool, conveyable through a wellbore string, extending into a subterranean formation, the wellbore string including a downhole flow control apparatus, the downhole flow control apparatus including a shearable closure member, wherein the downhole tool is co-operable with the downhole flow control apparatus such that, while the downhole tool is being conveyed downhole within the wellbore string, the downhole tool shears the closure member, with effect that flow communication is established between the wellbore string and the subterranean formation.
 2. The downhole tool as claimed in claim 1; wherein: the downhole tool includes a cutter; and the downhole tool is co-operable with the flow control apparatus, such that, while the downhole tool is being conveyed downhole within the wellbore string, the cutter is displaceable relative to the flow control apparatus for effectuating emplacement of the cutter for the shearing of the closure member.
 3. The downhole tool as claimed in claim 2; wherein: the displacement of the cutter, relative to the flow control apparatus, for effectuating emplacement of the cutter for the shearing of the shearable closure member, includes displacement of the cutter in a laterally outward direction, relative to a central axis of the downhole tool.
 4. The downhole tool as claimed in claim 2; wherein: the cutter is biased towards emplacement for the shearing of the shearable closure member, such that the displacement of the cutter is motivated by the bias.
 5. The downhole tool as claimed in claim 4; wherein: the downhole tool defines a tool profile co-operable with a flow communication-stimulating profile of the flow control apparatus, such that, while the downhole tool is being conveyed downhole within the wellbore string, in response to registration of the tool profile with the flow communication-stimulating profile, the displacement of the cutter, relative to the flow control apparatus, for effectuating the emplacement of the cutter for the shearing of the shearable closure member, is motivated by the bias.
 6. The downhole tool as claimed in claim 5; wherein: the downhole tool includes an elastically deformable portion; the elastically deformable portion and the cutter are co-operatively configured such that the cutter is displaceable with the elastically deformable portion; and the bias, motivating the displacement of the cutter, includes a bias motivating displacement of the elastically deformable portion.
 7. The downhole tool as clamed in claim 1; wherein; the downhole tool defines a tool profile and includes a cutter; the downhole tool is further co-operable with the downhole flow control apparatus for effectuating a profile-stimulated interaction; and the profile-stimulated interaction includes, in sequence, (i) a registration of the tool profile with a flow communication-stimulating profile, (ii) in response to the registration, a displacement of the cutter in a laterally outward direction, relative to a central axis of the downhole tool, and (iii) a conveyance of the downhole tool through the housing passage in a downhole direction, with effect that the shearing of the closure member by the cutter is effectuated.
 8. The downhole tool as claimed in claim 7; wherein: the displacement of the cutter, in a laterally outward direction, is motivated by the bias.
 9. The downhole tool as claimed in claim 8; wherein: the downhole tool includes an elastically deformable portion; the elastically deformable portion and the cutter are co-operatively configured such that the cutter is displaceable with the elastically deformable portion; and the bias, motivating the displacement of the cutter, includes a bias motivating displacement of the elastically deformable portion.
 10. The downhole tool as claimed in claim 1; wherein: the downhole tool is further co-operable with the apparatus such that conveyance of the downhole tool through the housing passage is with effect that, after the shearing of the closure member, the downhole tool becomes retained within the wellbore.
 11. The downhole tool as claimed in claim 10; wherein; the downhole tool defines a tool profile and includes a cutter; the downhole tool is further co-operable with the downhole flow control apparatus for effectuating, in sequence, a profile-stimulated interaction and a retention-effectuating interaction; the profile-stimulated interaction includes, in sequence, (i) a registration of the tool profile with a flow communication-stimulating profile of the flow control apparatus, (ii) in response to the registration, a displacement of the cutter in a laterally outward direction, relative to a central axis of the downhole tool, and (iii) a conveyance of the downhole tool through the housing passage in a downhole direction, with effect that the shearing of the closure member by the cutter is effectuated; and the retention-effectuating interaction includes, in sequence, (i) a registration of the tool profile with the non-release profile of the flow control apparatus, (ii) in response to the registration, a displacement of a retainable portion of the downhole tool in a laterally outward direction, relative to a central axis of the downhole tool, and (iii) a conveyance of the downhole tool through the housing passage in a downhole direction, with effect that the retainable portion becomes disposed in abutting engagement with the opposing surface of the non-release profile, such that the retention of the downhole tool, relative to the flow control apparatus is established.
 12. A downhole flow control apparatus for emplacement downhole as part of a wellbore string extending into a subterranean formation, comprising: a shearable closure member; wherein: the shearable closure member is shearable by a downhole tool being conveyed downhole within the wellbore string, with effect that flow communication is established between the wellbore string and the subterranean formation.
 13. The downhole flow control apparatus as claimed in claim 12; further comprising: a flow communication-stimulating profile configured for receiving a downhole tool, being conveyed downhole through the wellbore string, in response to a lateral displacement of the downhole tool, relative to a longitudinal axis of the wellbore string, such that the downhole tool becomes disposed for shearing the shearable closure member in response to axial displacement of the downhole tool through the wellbore string.
 14. The downhole flow control apparatus as claimed in claim 13; further comprising: a non-release profile for retaining the downhole tool; wherein: the shearable closure member and the non-release profile are co-operable with the downhole tool being conveyed through the wellbore string, such that, while the downhole tool is being conveyed downhole through the wellbore string, the downhole tool, in sequence: (i) shears the shearable closure member, and (ii) becomes retained to the non-release profile.
 15. A downhole flow control apparatus for emplacement downhole as part of a wellbore string extending into a subterranean formation, comprising: a housing, defining a housing passage; a shearable closure configuration; wherein: the shearable closure configuration and the housing passage being co-operatively configured such that, in response to shearing of the shearable closure configuration, flow communication is established between the housing passage and the environment external to the via a flow communication configuration, defined by at least one flow communicator; for each one of the at least one flow communicator, independently, the establishment of the flow communicator is responsive to shearing of a respective closure member configuration of the shearable closure configuration, such that the shearable closure configuration is defined by at least one closure member configuration; and for each one of the at least one closure member configuration, independently, the closure member configuration is defined by a respective at least one closure member, such that, for each one of the at least one flow communicator, the shearing of a respective closure member configuration of the shearable closure configuration, to which the establishment of the flow communicator is responsive, is defined by the shearing of the respective at least one closure member of the respective closure member configuration.
 16. The downhole flow control apparatus as claimed in claim 15; wherein: the at least one closure member configuration is a plurality of closure member configurations; and the plurality of closure member configurations are axially spaced apart relative to one another.
 17. The downhole flow control apparatus as claimed in claim 16; wherein: the plurality of closure member configurations are axially spaced apart relative to one another by a minimum spacing distance of at least five (5) feet.
 18. The downhole flow control apparatus as claimed in claim 15; wherein: the housing defines a flow communication-stimulating profile configuration, the flow communication-stimulating profile configuration is defined by at least one flow communication-stimulating profile, each one of the at least one flow communication-stimulating profile, independently, being configured for receiving a downhole tool, being conveyed downhole through the wellbore string passage, in response to a lateral displacement of the downhole tool, relative to a longitudinal axis of the wellbore string passage, such that the downhole tool becomes disposed for shearing of a respective at least one closure member configuration of the shearable closure configuration in response to axial displacement of the downhole tool, relative to the wellbore, and, for each one of the at least one flow communication-stimulating profile, independently, the shearing of the respective at least one closure member configuration, by the downhole tool received by the flow communication-stimulating profile, establishes, for each one of the respective at least one closure member configuration, independently, a respective one of the at least one flow communicator of the flow communicator configuration.
 19. The downhole flow control apparatus as claimed in claim 18; wherein: for each one of the at least one flow communication-stimulating profile, independently, the respective at least one closure member configuration is defined within the flow communication-stimulating profile.
 20. The downhole flow control apparatus as claimed in claim 18; wherein: each one of the at least one flow communication-stimulating profile, independently, is defined by a respective recess defined within the housing. 